A System And Method For Liquefying Variable Selected Quantities Of Light Hydrocarbon Gas With A Plurality Of Light Hydrocarbon Gas Liquefaction Trains

ABSTRACT

An improved system and method for providing reduced acid gas/dewatered light hydrocarbon gas to a light hydrocarbon gas liquefaction process wherein a plurality of light hydrocarbon gas liquefaction trains are used.

RELATED APPLICATIONS

This application is entitled to and hereby claims the benefit ofprovisional application Ser. No. 60/414,806 filed Sep. 30, 2002, theteachings of which are incorporated herein by reference in theirentirety.

FIELD OF THE INVENTION

This invention relates to an improved system and method for liquefyingvariable selected quantities of light hydrocarbon gas to produceliquefied light hydrocarbon gas using a plurality of light hydrocarbongas liquefaction trains using shared facilities.

BACKGROUND OF THE INVENTION

Many light hydrocarbon gas reserves are found in areas of the world thatare remote to any markets for the light hydrocarbon gas. Such lighthydrocarbon gas is referred to as natural gas. This natural gas maycontain condensates that are light gasoline boiling range materials aswell as C₃-C₅ gaseous hydrocarbons and methane.

Frequently such natural gas also contains undesirably high quantities ofwater, acid gas compounds such as sulfur compounds, carbon dioxide andthe like for liquefaction to produce liquefied light hydrocarbon gases,which typically comprise primarily methane and which are frequentlyreferred to as liquefied natural gas (LNG).

When such gases are liquefied, the capacity of the liquefaction plant isdetermined primarily by the available market for the gas, theavailability of transportation to the market and the like. Accordinglyin many instances it is desirable to increase the capacity of theliquefaction process in incremental stages as the market expands toremain in balance with the available market. Accordingly lighthydrocarbon gas liquefaction processes, referred to herein as naturalgas liquefaction processes or LNG processes, are typically installed intrains. The term “train” as used processes, are typically installed intrains. The term “train” as used herein refers to a series of vesselscapable of, pre-treating and liquefying natural gas. The gas indesirably treated to remove acid gases and water to very low levelsprior to charging it to the liquefaction zone. The train also includescompression facilities for compressing the refrigerant required for therefrigeration vessel and the like. The train is an integrated processfor producing a selected quantity of liquefied natural gas. Additionaltrains are added as capacity is required to meet the available marketdemand and the like.

In FIG. 1, a light hydrocarbon gas liquefaction system and process(train) is schematically shown. The system and process, as shown,includes a refrigeration facility 12. As shown, compressed refrigerantis supplied to facility 12 by turbines 14 and 16, which are shaftcoupled by shafts 18 and 20 to refrigerant compressors 22 and 24.Low-pressure refrigerant is supplied to compressors 22 and 24 bylow-pressure refrigerant lines 26 and 28. These lines typically returnlow-pressure refrigerant from facility 12 after it has served itspurpose as a refrigerant and has been warmed to a substantially gaseouscondition. Compressed refrigerant is supplied via a line 30 to facility12 and via a line 32 to facility 12. As shown, these lines enterfacility 12 at different points. No significance should be attributed tothis except that refrigerants can be produced from compressors 22 and 24at different pressures if desired and passed to facility 12 differentpoints in the refrigeration process as desired. Spent refrigerant isalso shown as recovered through lines 26 and 28 to compressors 22 and 24respectively. The same or different refrigerants can be used,refrigerants at a different pressures can be used and the like as wellknown to those skilled in the art.

Further an inlet light hydrocarbon gas which has desirably been treatedto remove acid gases and water and is charged to facility 12 via a line34. A liquefied light hydrocarbon gas is produced through line 36. Awide variety of refrigeration processes are contemplated within thescope of the present invention. No novelty is claimed with respect tothe particular type of refrigeration process or vessel used. The processof the present invention is considered to be useful with any type ofliquefaction process that requires light hydrocarbon gas as an inletstream.

Typically a natural gas or other light hydrocarbon gas stream inintroduced through a line 40 and passed to an acid gas removal vessel44. An acid gas regenerator 44 is shown in fluid communication withvessel 46 via lines 38 and 50. The treated gas is typically recoveredfrom vessel 44 through line 48. The recovered gases are passed via alines 54 and 56 to one or the other of dewatering vessels 58 and 60.Typically vessel 44 is an aqueous amine scrubber and operates as wellknown to those skilled in the art. The aqueous amine may be selectedfrom materials such as digycolanolamine (DEA), methyldiethanolamine(MDEA), methylethylanolamine (MEA), sulfinol (trademark of Shell Oil Cofor amine for acid gas removal) and combinations thereof. The Co₂ istypically removed to levels less than about 100 parts per million (ppm)and sulfur is typically removed to levels less than about 16 ppm.

The operation of such acid gas removal vessels, as shown, is well known.Since each train is typically constructed separately as demand requires,it is common to provide an acid gas removal vessel and an acid gasregenerator, for each train.

Since the aqueous amine process produces a gas that is relativelysaturated in water and since the water freezes at a temperature muchhigher than methane, which constitutes the majority of the natural gasstream to be liquefied, it is necessary that at least a major portion ofthe water to be removed. This is typically accomplished by passing thestream containing the water after acid gas removal through lines 54 or56 into molecular sieve vessels 58 and 60 where the water is selectivelyremoved to produce a dewatered gas that is recovered through lines 62and 64. This dewatered stream is passed through line 34 into facility12.

In the use of dewatering vessels 58 and 60, one of the vessels is useduntil it becomes spent and then the flow of gas is switched to the othervessel with the first vessel then being regenerated while the secondvessel is in service. Typically two vessels are placed in each train tomeet the requirements to dewater the incoming gas. Typically vessels 50and 60 include an absorption material such as a molecular sieve,activated alumina and the like. This material is effective to removewater from a gaseous stream to extremely low levels and to render thegaseous stream suitable for liquefaction in facility 12. Such molecularsieves are typically regenerated by passing a heated gas through thevessel to remove water.

The desulfurization vessels are readily regenerated as well known tothose skilled in the art by a variety of techniques. One commonly usedtechnique is the use of a reboiler (not shown) on vessel 46 for theregeneration.

Clearly the construction of separate trains of refrigeration processesas discussed above results in the expenditure of considerable capital toduplicate facilities in each turn such as the dewatering and acid gasremoval vessels and regeneration vessels. Accordingly a continuingsearch has been directed to the development of systems and methods forreducing the unnecessary expense for these duplicate vessels.

SUMMARY OF THE INVENTION

According to the present invention, it has now been found that theexpense required for these vessels can be reduced by a method fordesigning an efficient and economical light hydrocarbon gas liquefactionprocess for the liquefaction of selected quantities of light hydrocarbongas in a first light hydrocarbon gas liquefaction train and up to aselected maximum quantity of light hydrocarbon gas using a plurality oflight hydrocarbon gas liquefaction trains, the method comprising:

a) designing a first light hydrocarbon gas liquefaction process trainincluding facilities for light hydrocarbon gas pretreatment to removeacid gases and water, refrigerant compression, access services, lighthydrocarbon gas liquefaction, and liquefied light hydrocarbon gasproduct storage and shipping;

b) designing at least a portion of the facilities in the first train forshared use by the first train and subsequent trains;

c) designing at least a portion of the first train facilities for shareduse with modular expansion, as required by the addition of subsequenttrains, up to the maximum capacity required to liquefy the maximumquantity of light hydrocarbon gas or initially designing the portion ofthe first train facilities for shared use of a size sufficient toliquefy the maximum quantity of light hydrocarbon gas.

It has further been found that an improvement is achieved by a methodfor efficiently and economically constructing a light hydrocarbon gasliquefaction process for the liquefaction of selected quantities oflight hydrocarbon gas in a first light hydrocarbon gas liquefactiontrain and up to a selected maximum quantity of liquefied lighthydrocarbon gas using a plurality of light hydrocarbon gas liquefactiontrains, the method comprising:

a) constructing a first light hydrocarbon gas liquefaction process trainfor the liquefaction of a first selected quantity light hydrocarbon gasincluding facilities for light hydrocarbon gas pretreatment to removeacid gases and water, refrigerant compression, access services, lighthydrocarbon gas liquefaction, and liquefied light hydrocarbon gasproduct storage and shipping;

b) constructing at least a portion of the facilities in the first trainfor shared use by the first train and subsequent trains;

c) constructing at least a portion of the first train facilities forshared use with modular expansion, as required by the addition ofsubsequent trains, up to the maximum capacity required to liquefy themaximum quantity of light hydrocarbon gas or initially constructing theportion of the first train facilities for shared used of a sizesufficient to liquefy the maximum quantity of light hydrocarbon gas;

d) constructing additional trains as required to liquefy a secondselected quantity of light hydrocarbon gas;

e) providing at least a portion of the facilities in the additionaltrains by shared use of the shared use facilities in the first train asconstructed in the first train or as constructed in the first train andexpanded to the required capacity;

g) liquefying the second selected quantity of light hydrocarbon gas toproduce a selected quantity of liquefied light hydrocarbon gas product.

It has been found that an improvement is achieved by a method forefficiently and economically operating a light hydrocarbon gasliquefaction process for the liquefaction of selected quantities oflight hydrocarbon gas in a first light hydrocarbon gas liquefactiontrain and up to a selected maximum quantity of liquefied lighthydrocarbon gas using a plurality of light hydrocarbon gas liquefactiontrains, the method comprising:

a) constructing a first light hydrocarbon gas liquefaction process trainfor the liquefaction of a first selected quantity light hydrocarbon gasincluding facilities for light hydrocarbon gas pretreatment to removeacid gases and water, refrigerant compression, access services, lighthydrocarbon gas liquefaction, and liquefied light hydrocarbon gasproduct storage and shipping;

b) constructing at least a portion of the facilities in the first trainfor shared use by the first train subsequent trains;

c) constructing at least a portion of the first train facilities forshared use for modular expansion, as required by the addition ofsubsequent trains, up to the maximum capacity required to liquefy themaximum quantity of light hydrocarbon gas or initially designing theportion of the first train facilities for shared use of a sizesufficient to liquefy the maximum quantity of light hydrocarbon gas;

d) constructing additional trains as required to liquefy a secondselected quantity of light hydrocarbon gas;

e) providing at least a portion of the facilities in the additionaltrains by shared use of the shared use facilities in the first train asconstructed in the first train or as constructed in the first train andexpanded to the required capacity;

f) processing light hydrocarbon gas for the first train and theadditional trains in at least a portion of the shared facilities; and

g) liquefying the second selected quantity of light hydrocarbon gas toproduce a selected quantity of liquefied light hydrocarbon gas product.

It has now been found that the expense required for these vessels isreduced by a method for removing acid gases from a light hydrocarbon gasfeed stream to each of a plurality of light hydrocarbon gas liquefactiontrains, the method comprising: a) providing a plurality of lighthydrocarbon gas acid gas removal vessels, each of the vessels beingadapted to remove acid gases from a light hydrocarbon gas feed streamfor a light hydrocarbon gas liquefaction train; b) passing a first lighthydrocarbon gas feed stream through a first light hydrocarbon gas acidgas removal vessel to produce a first light hydrocarbon gas feed streamhaving a reduced acid gas content for a first light hydrocarbon gasliquefaction train; c) passing a second light hydrocarbon gas feedstream through a second light hydrocarbon gas acid gas removal vessel toproduce a second light hydrocarbon gas feed stream having a reduced acidgas content for a second light hydrocarbon gas liquefaction train; and,d) regenerating the first spent light hydrocarbon gas acid gas removalvessels for re-use to remove acid gas from light hydrocarbon gasstreams.

It has further been found that the expense for equipment for dewateringthe gas stream is reduced by a method for removing water from a lighthydrocarbon gas feedstream to each of a plurality of light hydrocarbongas liquefaction trains, the method comprising: a) providing a pluralityof light hydrocarbon gas dewatering molecular sieve vessels, each of thevessels being adapted to dewater a light hydrocarbon gas feed stream toa light hydrocarbon gas liquefaction train; b) passing a first lighthydrocarbon gas feed stream through a first light hydrocarbon gasmolecular sieve vessel to produce a first dewatered light hydrocarbongas feed stream for a first light hydrocarbon gas liquefaction train; c)passing a second light hydrocarbon gas feed stream through a secondlight hydrocarbon gas dewatering molecular sieve vessel to produce asecond dewatered light hydrocarbon gas feed stream for a second lighthydrocarbon gas liquefaction train; d) switching the first lighthydrocarbon gas stream from the first light hydrocarbon gas dewateringmolecular sieve vessel when the first light hydrocarbon gas dewateringvessel is spent and passing the first light hydrocarbon gas streamthrough another of the plurality of light hydrocarbon gas dewateringvessels to produce the first dewatered light hydrocarbon gas feed streamfor the first light hydrocarbon gas liquefaction train; and, e)regenerating the first spent light hydrocarbon gas dewatering molecularsieve vessel for re-use to dewater a light hydrocarbon gas stream.

It has further been found that the expense for removing acid gases anddewatering a light hydrocarbon gas feed stream is substantially reducedby a method for removing acid gases and dewatering a light hydrocarbongas feed stream to each of a plurality of light hydrocarbon gasliquefaction trains, the method comprising: a) providing a plurality oflight hydrocarbon gas acid gas removal vessels, each of the vesselsbeing adapted to remove acid gases from a light hydrocarbon gas feedstream to a light hydrocarbon gas liquefaction train; b) passing a firstlight hydrocarbon gas feed stream through a first light hydrocarbon gasacid gas removal vessel to produce a first light hydrocarbon gas feedstream having a reduced acid gas content for a first light hydrocarbongas liquefaction train; c) passing a second light hydrocarbon gas feedstream through a second light hydrocarbon gas acid gas removal vessel toproduce a second light hydrocarbon gas feed stream having a reduced acidgas content for a second light hydrocarbon gas liquefaction train; d)regenerating the first spent light hydrocarbon gas acid gas removalvessels for re-use to remove acid gas from light hydrocarbon gasstreams; e) providing a plurality of light hydrocarbon gas dewateringmolecular sieve vessels, each of the vessels being adapted to dewater alight hydrocarbon gas feed stream to a light hydrocarbon gasliquefaction train; f) passing a first light hydrocarbon gas feed streamthrough a first light hydrocarbon gas dewatering vessel to produce afirst dewatered light hydrocarbon gas feed stream for a first lighthydrocarbon gas liquefaction train; g) passing a second lighthydrocarbon gas feed stream through a second light hydrocarbon gasdewatering molecular sieve vessel to produce a second dewatered lighthydrocarbon gas feed stream for a second light hydrocarbon gasliquefaction train; h) switching the first light hydrocarbon gas streamfrom the first light hydrocarbon gas dewatering molecular sieve vesselwhen the first light hydrocarbon gas dewatering vessel is spent andpassing the first light hydrocarbon gas stream through another of theplurality of light hydrocarbon gas dewatering vessels to produce thefirst dewatered light hydrocarbon gas feed stream for the first lighthydrocarbon liquefaction train; and, i) regenerating the first spentlight hydrocarbon gas dewatering molecular sieve vessel for re-usedewater a light hydrocarbon gas stream.

The invention further comprises a system for removing acid gases from alight hydrocarbon gas feed stream to each of a plurality of lighthydrocarbon gas liquefaction trains, the system comprising:

a) a plurality of aqueous amine acid gas removal vessels, each of thevessels having a gas inlet and a gas outlet so that an inlet gas can becharged to each acid gas removal vessel and a gas having a reduced acidcontent recovered from each acid gas removal vessel;

b) a gas supply line in fluid communication with each gas inlet;

c) a treated gas recovery line in fluid communication with each gasoutlet;

d) a regenerated aqueous amine inlet to each acid gas removal vessel;

e) a spent aqueous amine outlet from each acid gas removal vessel; and,

f) a spent aqueous amine regenerator in fluid communication with atleast one selected regenerated aqueous amine inlet and with at least oneselected spent aqueous amine outlet.

The invention also comprises a system for dewatering a light hydrocarbongas feed stream to each of a plurality of light hydrocarbon gasliquefaction trains, the system comprising: a) a plurality of aqueousamine molecular sieve dewatering vessels, each of the vessels having agas inlet and a dewatered gas outlet so that an inlet gas can be chargedto each dewatering vessel and a desulfurized gas recovered from eachdewatering vessel; b) a gas supply line in fluid communication with eachgas inlet, c) a gas recovery line in fluid communication with eachdewatered gas outlet line; and, d) a regeneration outlet line in fluidcommunication with each dewatering vessel.

The invention further comprises a system for removing acid gases anddewatering a light hydrocarbon gas feed stream to each of a plurality oflight hydrocarbon gas liquefaction trains, the system comprising:

a plurality of aqueous amine acid gas removal vessels, each of thevessels having a gas inlet and a gas outlet so that an inlet gas can becharged to each acid gas removal vessel and a gas having a reduced acidcontent recovered from each acid gas removal vessel;

b) a gas supply line in fluid communication with each gas inlet;

c) a reduced acid gas content gas recovery line in fluid communicationwith each gas outlet;

d) a regenerated aqueous amine inlet to each acid gas removal vessel;

e) a spent aqueous amine outlet from each acid gas removal vessel; and,

f) a plurality of molecular sieve dewatering vessels, each of thedewatering vessels having a gas inlet and a dewatered gas outlet so thatan inlet gas can be charged to each dewatering vessel and a dewateredgas recovered from each dewatering vessel;

g) a gas supply line in fluid communication with each gas inlet;

h) a dewatered gas recovery line in fluid communication with eachdewatered gas outlet line and;

i) a regeneration outlet line in fluid communication with each dewateredvessel so that each dewatering vessel can be thermally regenerated.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic diagram of an embodiment of a light hydrocarbongas liquefaction train;

FIG. 2 is a schematic diagram of light hydrocarbon gas liquefactionprocess according to the process of the present invention including twotrains;

FIG. 3 is a schematic diagram of an embodiment of an acid gas removalfacility according to the present invention;

FIG. 4 is a schematic diagram of a facility for dewatering according tothe present invention.

DESCRIPTION OF PREFERRED EMBODIMENTS

In the description of the Figures, numerous pumps, valves and the like,necessary to achieve the flows shown, known to those skilled in the arthave not been shown for simplicity.

The present invention provides an improved efficiency and economy inoperating a light hydrocarbon gas liquefaction process for theliquefaction of selected quantities of light hydrocarbon gas in a firstlight hydrocarbon gas liquefaction train and up to a selected maximumquantity of liquefied light hydrocarbon gas using a plurality of lighthydrocarbon gas liquefaction trains by a method comprising the design ofsuch processes to include certain facilities which are common to most ifnot all gas liquefaction processes. As indicated the term “lighthydrocarbon gas liquefaction train” or “train” refers to those units andfacilities used for pretreatment and post-treatment of the gas feeds tothe liquefaction facility as well as the facilities for compressing therefrigerant and the like as shown in FIG. 1. Since these requirementsare common to substantially all liquefaction trains they are normallyfound in each liquefaction trains. Vessels for the removal of acid gasesand for dewatering typically include both an absorption vessel and aregenerator vessel to regenerate the media used in the vessel for acidgas removal or for dewatering respectively. For example in the acid gasremoval section and absorption vessel and a regeneration vessel arerequired. If these facilities are duplicated in each train then eachtrain will include an absorption vessel and a regenerator vessel.Clearly an economy could be realized if upon design and construction ofthe first train the train was designed and constructed to includeregenerator for the aqueous amine used in the acid gas absorptionvessels of a size sufficient to accommodate additional absorptionvessels as required as additional trains were added. Desirably thisequipment is located in an area which is equally accessible or at leastaccessible to each of the trains so that additional acid gas removalvessels can be positioned to serve each train and remain in fluidcommunication with the regenerator vessel for the regeneration andrecycling of the aqueous amine solution used for the acid gasabsorption. For instance these vessels could be commonly sited with thegas from which the acid gases have been removed being then passed to theappropriate liquefaction facility. This results in the construction ofonly a single aqueous amine regeneration vessel and permits theconstruction of only an additional acid gas absorption vessel for eachliquefaction train.

Similarly when dewatering vessels are used two are typically constructedfor each train. One is used for absorption of water with the secondbeing regenerated by hot gas to drive out the water during the period ofuse of the first vessel. When the estimated maximum quantity of gas tobe produced is known then a plurality of dewatering vessels can beplaced together at a common site to dewater the reduced acid gas contentgas produced by the removal of the acid gases to produce a dewateredlight liquid hydrocarbon gas stream having a reduced acid gas content.It is well known that the regeneration times for such vessels issubstantially less than the time required on line for dewatering. Priorpractice has been to provide two dewatering vessels for each train sothat one vessel is on line while the other is regenerated. If thevessels are located at a common site only a single vessel can be addedfor the second train. The single vessel is sufficient since the twovessels which are operative at any given time will operate for longenough to provide time to regenerate the third vessel. When the thirdvessel is regenerated the gas flow from one of the other vessels whichmay have become spent can be rerouted to the regenerated vessel with thevessel which has become spent then being regenerated. By the use of thevessels in this fashion a plurality of vessels can be used without theneed to produce a second vessel for regeneration for each dewateringvessel. These vessels can be used in groups wherein the number ofvessels usable in a group is equal to a number equal to the run time foreach vessel divided by the regeneration time to produce a number whichis a whole number disregarding any fraction plus one. This numberdefines the number of vessels which can be used with one additionalvessel for regeneration. In the event that the regeneration time isequal to one third of the run time then four vessels can be used toservice three trains rather than the six vessels which would normally beconstructed according to the prior art. Similarly improvements can berealized in the construction of docking facilities, liquid natural gasstorage and shipping facilities, C₃+ hydrocarbon removal facilities andthe like.

According to the present invention these facilities are produced in aform in the first train from which they can be expanded by modularincrements or of a size necessary to handle the maximum quantity oflight hydrocarbon gas which will be processed through the liquefactionprocess.

Typically, such processes are expanded by adding trains and as indicatedpreviously by adding all the facilities required for each train in eachtrain. According to the present invention shared facilities are used bythe first liquefaction train and the subsequent liquefaction trains. Theinitial or first liquefaction train is designed to size the sharedequipment of a size capable of handling the maximum capacity expected bythe combination of liquefaction trains or in a form adapted toincremental expansion as additional trains are added. For instance inFIG. 2 it is disclosed that less than a full amount of compressedrefrigerant may be charged in a second liquefaction train initially.This permits addition of the train before a market exists for all of theliquefied natural gas which could be produced through the two trainsystem. It also permits ready expansion of this system when the marketexpands to include a full compressed refrigerant charge to the secondtrain liquefaction facility.

The improvement of the present invention is readily achieved by a methodfor designing a process to achieve these advantages by the constructionof a process to achieve these advantages and by operation of the processto realize these advantages.

For instance in FIG. 2 a two train process is shown. The first traincomprises turbines 100 and 102 which are coupled to refrigerantcompressors 106 and 108 with the refrigerant being passed via lines 114and 116 to a liquefaction facility 118. A liquefied natural gas productis recovered via a line 126 from liquefaction facility 118 and passed toproduct storage and export facility 130. A second train is shown whereina turbine 103 and a turbine 104 which is shown in dotted lines toindicate that this turbine is not present, but is contemplated inconjunction with the second train, are shown connected to a refrigerantcompressor 110 and a refrigerant compressor 112 which is alsocontemplated for addition. The compressor refrigerant from compressor110 is passed via a line 122 to a refrigerant facility 120 with thecontemplated compressed refrigerant from compressor 112 being passed viaa line 124 to facility 120 when compressor 112 is added. The inlet gasis supplied through a line 132 to an acid gas removal section 134 whereit is treated for the removal of acid gas and passed through a line 136to a dewatering section 138. In dewatering section 138 water is removedfrom the light hydrocarbon gas stream and it is passed via a line 140 toa C₃+ heavier hydrocarbon removal section 142. The gas after treatmentin section 142 is passed through a line 144 to line 146 into facility118 or a line 148 into a facility 120. Liquefied light hydrocarbon gasfrom facility 120 is recovered via a line 128.

In the operation of the process shown in FIG. 2 the inlet gas is treatedfor the removal of acid gas, water and hydrocarbon gases heavier thanabout C₃. In the facilities used to treat the gas, the gas inlet streamis treated for the removal of these components from the gas inlet toboth facility 118 and facility 120. This is achieved by positioning therespective facilities in fluid communication with the liquefactionfacilities. This arrangement permits the use of shared facilities andachieves the economies discussed above.

Various more specific applications of the use of shared acid gas removalfacilities and dewatering facilities are discussed below.

FIG. 1 has been discussed above.

In FIG. 1 a regenerator vessel 46 is equipped to use at least one of astripping gas and a reboiler or the like (heat source not shown) toregenerate spent aqueous amine solutions for use in acid gas removalvessel 44 is shown. The regeneration removes carbon dioxide, hydrogensulfide and the like with the regenerated aqueous amine being returnedvia a line 38 to an upper portion of vessel 44 with spent amine beingwithdrawn from vessel 44 through a line 50 and passed into regenerator46 for regeneration and return to vessel 44. The operation of suchvessels, as shown, is well known to those skilled in the art.

According to the present invention, it is desirable that the facilitiesrequired for acid gas removal and for dewatering be arranged in a commonarea, or at least in common fluid communication. In FIG. 3, a system isshown wherein four acid gas removal vessels 200, 202, 204 and 206 areavailable for use to remove acid gases from inlet gas streams, which arecharged to the process through a line 210. The inlet gas may be passedvia lines 212, 214, 216 and 218, to any or all of the acid gas removalvessels 200, 202, 204 and 206. The acid gas removal vessels showncontain aqueous amine solutions and operate as discussed in connectionwith FIG. 1.

The gaseous streams having reduced acid gas contents are recoveredthrough lines 224, 226, 228 and 230. The gas stream having a reducedacid is recovered through a line 244. Any or all of the acid gas removalvessels can be used with it being anticipated that one such vessel willbe used for each train so that no additional regeneration vessel isrequired for the train. Desirably a plurality of trains are serviced bythe acid gas removal facility shown in FIG. 3. One or more acid gasremoval vessels may be constructed with the first train with theregeneration vessel being sized to handle enough such vessels to servicethe trains required to achieve the maximum design capacity for theentire liquefaction process including all trains.

As shown, the facility could attend to the acid gas removal needs forfour trains with regeneration occurring in a regenerator vessel 208. Theregeneration of the aqueous amine in vessel 208 may employ the use of areboiler (not shown) to heat the aqueous amine solution with or withoutuse of a stripping gas introduced through a line 242 to regenerate theaqueous amine solution by driving off acid gases such as carbon dioxide,hydrogen sulfide and the like for recovery through a line 240. The freshamine is produced via a line 244 and passed through lines 246, 248, 250and 252 into the upper portion of vessels 200, 202, 204, and 206 withspent amine being recovered through lines 230, 232, 234, and 236. Thespent amine is passed via a line 238 to regenerator 208.

In the operation of the process, a regenerated aqueous amine solution isprovided to the upper portion of each vessel on a continuous basis witha spent amine solution being recovered from the lower portion of thevessel and passed back to regeneration. Vessel 208, however, must besized to provide sufficient fresh regenerated aqueous amine to removethe acid gas compounds from the gaseous stream charged to the selectedones of vessels 200, 202,204 and 206. In the operation of the process,for instance if two refrigeration trains are in operation and usingvessels 200 and 202 then vessels 204 and 206 would be idle and availablefor use by additional trains. In the event that a third train is added,vessel 204 could be placed in use for the third train with capacity fora fourth train being available in vessel 206. The sizing of vessel 208entails little additional expense to provide sufficient regeneratingcapacity to provide sufficient regenerated amine to service all four ofvessels.

Thus, additional trains can be added without additional expense or bysimply adding an additional acid gas removal vessel. So long assufficient regeneration capacity exists in regenerator 208, the additionof additional trains is at a considerably reduced capital cost by virtueof requiring only the additional of a single acid gas removal vesselrather than an acid gas removal vessel and a regeneration vessel.

In a preferred embodiment shown in FIG. 4, an arrangement of vesselssuitable for use for dewatering a light hydrocarbon gas stream has beenshown. An inlet gas stream is received through a line 308 and may bepassed to selected one of vessels 300, 302, 304 and 306. The inlet gaspasses to the vessels through lines 310, 312, 314 and 316 respectively.The gas is treated in vessels 300, 302, 304 and 306 to remove water fromthe gaseous stream. The product streams are recovered through lines 318,320, 322 and 324 respectively. The product gases are recovered through aline 326. For purposes of regeneration, a stripping gas may beintroduced through a line 328 to each vessel through lines 330, 332, 334and 336 respectively.

Typically the regeneration is by heat and the heat may be supplied forthe regeneration by a hot gas flow through the dewatering vessels. Ineither event, whether the stripping gas is or is not used, dischargedgases will be released through lines 338, 340, 342 and 344. These gasesare recovered through a line 346 and passed to recovery or otherprocessing as desired.

In the embodiment, shown in FIG. 4 the number of vessels shown isappropriate for a process wherein the run time of each vessel indewatering service is equal to three times the time required forregeneration. Accordingly, with four vessels, three trains can beserviced with the regeneration of each vessel occurring while the otherthree are in use. For instance, if the vessels are started at a sequencewhich will result in them becoming spent at intervals of one-third oftheir lives, then when vessel 300 is spent the gas flow directed tovessel 300 can be switched to vessel 306 with vessels 302 and 304remaining in service. Vessel 300 is regenerated and when vessel 302 isspent the gas flow previously directed to vessel 302 is switched tovessel 300 and regeneration of vessel 302 begins. When vessel 304 isspent then vessel 302 will have been regenerated and production can beswitched to vessel 302 and the like. Four dewatering vessels can be thusused to service three refrigeration trains. The maximum number ofvessels used in such an arrangement is equal to the lowest whole numberdefined by division of the run time for each vessel by the regenerationtime, plus one. This relationship can be expressed as:${{maximum}\quad{number}} = {\frac{{run}\quad{time}}{{regeneration}\quad{time}}\left( {{whole}\quad{number}\quad{without}\quad{regard}\quad{to}\quad{any}\quad{fraction}} \right) + 1}$Clearly operation as shown in FIG. 4 has resulted in the elimination oftwo vessels from the total required vessels for the of the inlet gasstream as previously practiced. Previously the dewatering vessels wereprovided for each train in pairs. Accordingly the four vessel operationabove has reduced the number of required dewatering vessels from six tofour.

According to the present invention, an improved system and method forproducing desulfurized, dewatering gas for refrigeration processescomprising a plurality of refrigeration trains has been shown. It willbe readily appreciated by those skilled in the art, upon review of FIG.4 particularly, that when more trains are present then can beaccommodated with the arrangement shown in FIG. 4 based upon theregeneration times and the run times, then clearly a second system ofthe same type can be installed with a similar improvement for futuretrains beyond the number defined above.

By the present invention, three trains can be serviced with the samenumber of vessels with are normally used for two trains. This is clearsaving of both capital and operating expense for two additional vesselswhile accomplishing the same results by the apparatus shown in FIG. 4.Clearly different numbers of vessels can be used depending upon thedifferent run times and regeneration times for the particular system.

According to the present invention improved efficiency and economy havebeen achieved by including in a first train of a light hydrocarbon gasliquefaction process shared facilities which can be used by second andsubsequent liquefaction trains by either modularization or by use of thefacilities which are designed for the desired maximum number ofliquefaction trains initially. This results in substantial savings inthe overall operation of the process at maximum capacity and providesfor great ease in expanding the process incrementally. For instance inthe treatment of the light hydrocarbon gas streams improved economy canbe achieved as discussed by adding a regeneration section which is of asize suitable to regenerate aqueous amine for all of the acid gasremoval vessels which are contemplated at maximum capacity of thepresent comprising all of the trains in combination. While this capacitymay not be achieved for many years the added cost of the larger vesselis relatively minor compared to the savings by comparison to the use ofa second regeneration vessel and a second acid gas removal vessel fortrain. Similarly the use of the dewatering vessels as discussed abovehas resulted in substantial savings. For instance even when only twovessels are used initially the addition of a third vessel for operationin this fashion permits the addition of a second train but with theaddition of only a single dewatering vessel rather than the pair ofdewatering vessels usually required. Further as noted in FIG. 2 in theevent that less than a full liquefaction facility is required for thedesired increase in capacity the added liquefaction facility can beadded with a reduced light hydrocarbon gas flow with a reduced quantityof compressed refrigerant to produce a liquefied light hydrocarbon gasstream in a quantity suitable to meet the current demand. Similarlydocking facilities, access roads, C₃+ hydrocarbon removal facilities andthe like can all be designed for either modular expansion or of a sizeto accommodate the maximum plant size initially with the resultingefficiency in process expansion when required and economies achieved byreducing the duplication of equipment.

While the present invention has been described by reference to certainof its preferred embodiments, it is pointed out that the embodimentsdescribed are illustrative rather than limiting in nature and that manyvariations and modifications are possible within the scope of thepresent invention. Many such variations and modifications may beconsidered obvious and desirable by those skilled in the art based upona review of the foregoing description of preferred embodiments.

1. A method for removing and gases from a light hydrocarbon gas feedstream to each of a plurality of light hydrocarbon gas liquefactiontrains, the method comprising: a) providing a plurality of lighthydrocarbon gas acid removal vessels, each of the vessels containing anaqueous amine and being adapted to remove acid gas from a lighthydrocarbon gas feed stream to a light hydrocarbon gas liquefactiontrain; b) passing a first light hydrocarbon gas feed stream through afirst light hydrocarbon gas acid gas removal vessel to produce a lighthydrocarbon gas feed stream having a reduced acid gas content for afirst light hydrocarbon gas liquefaction train; c) passing a secondlight hydrocarbon gas feed stream through a second light hydrocarbon gasacid gas removal vessel to produce a second light hydrocarbon gas feedstream having a reduced acid gas content for a second light hydrocarbongas liquefaction train; and d) regenerating a spent aqueous amine fromthe acid gas removal vessels and returning regenerated aqueous amine tothe acid gas removal vessels.
 2. The method of claim 1 wherein theaqueous amine comprises an amine selected from the group consisting ofdiglycolanolamine, methyldiethanolamine, methylethylanolamine, SULFINOLand combinations thereof.
 3. A method for removing water from a lighthydrocarbon gas feedstream to each of a plurality of light hydrocarbongas liquefaction trains, the method comprising: a) providing a pluralityof light hydrocarbon gas dewatering molecular sieve vessels, each of thevessels being adapted to dewater a light hydrocarbon gas feed stream toa light hydrocarbon gas liquefaction train; b) passing a first lighthydrocarbon gas feed stream through a first light hydrocarbon gasdewatering vessel to produce a first dewatered light hydrocarbon gasfeed stream for a first light hydrocarbon gas liquefaction train; c)passing a second light hydrocarbon gas feed stream through a secondlight hydrocarbon gas dewatering molecular sieve vessel to produce asecond dewatered light hydrocarbon gas feed stream for a second lighthydrocarbon gas liquefaction train; d) switching the first lighthydrocarbon gas stream from the first light hydrocarbon gas dewateringmolecular sieve vessel when the first light hydrocarbon gas dewateringvessel is spent and passing the first light hydrocarbon gas streamthrough another of the plurality of light hydrocarbon gas dewateringvessels to produce the first dewatered light hydrocarbon gas feed streamfor the first light hydrocarbon gas liquefaction train; and, e)regenerating the first spent light hydrocarbon gas dewatering molecularsieve vessel for re-use to dewater a light hydrocarbon gas stream. 4.The method of claim 3 wherein the number of light hydrocarbon gasdewatering vessels is a whole number which is less than or equal to theaverage run time of the light hydrocarbon gas vessels for dewateringdivided by the regeneration time for a light hydrocarbon gas dewateringmolecular sieve vessels plus one or a whole number of multiples of thenumber.
 5. The method of claim 3 wherein the light hydrocarbon gasdewatering molecular sieve vessels contain a molecular sieve oractivated alumina.
 6. The method of claim 3 wherein the spent vessel isthermally regenerated.
 7. A method for removing acid gas and dewateringa light hydrocarbon gas feed stream to each of a plurality of lighthydrocarbon gas liquefaction trains, the method comprising: a) providinga plurality of light hydrocarbon gas acid removal vessels, each of thevessels containing an aqueous amine and being adapted to remove acid gasfrom a light hydrocarbon gas feed stream to a light hydrocarbon gasliquefaction train; b) passing a first light hydrocarbon gas feed streamthrough a first light hydrocarbon gas acid gas removal vessel to producea light hydrocarbon gas feed stream having a reduced acid gas contentfor a first light hydrocarbon gas liquefaction train; c) passing asecond light hydrocarbon gas feed stream through a second lighthydrocarbon gas acid gas removal vessel to produce a second lighthydrocarbon gas feed stream having a reduced acid gas content for asecond light hydrocarbon gas liquefaction train; d) regenerating a spentaqueous amine from the acid gas removal vessels and returningregenerated aqueous amine to the acid gas removal vessels; e) producinga plurality of light hydrocarbon gas dewatering molecular sieve vessels,each of the vessels being adapted to dewater a light hydrocarbon gasfeed stream to a light hydrocarbon gas liquefaction train; f) passing afirst light hydrocarbon gas feed stream having a reduced acid gascontent through a first light hydrocarbon gas dewatering molecular sievevessel to produce a first dewatered light hydrocarbon gas feed streamhaving a reduced acid gas content for a first light hydrocarbon gasliquefaction train; g) passing a second light hydrocarbon gas feedstream having a reduced acid gas content through a second lighthydrocarbon gas dewatering molecular sieve vessel to produce a seconddewatered light hydrocarbon gas feed stream having a reduced acid gascontent for a second light hydrocarbon gas liquefaction train; h)switching the first light hydrocarbon gas stream from the first lighthydrocarbon gas dewatering molecular sieve vessel when the first lighthydrocarbon gas dewatering molecular sieve vessel is spent and passingthe first light hydrocarbon gas stream through another of the pluralityof light hydrocarbon gas dewatering molecular sieve vessels to produce afirst light hydrocarbon gas feed stream having a reduced acid gascontent and a reduced water content for the first light hydrocarbon gasliquefaction train; and, i) regenerating the first spent lighthydrocarbon gas dewatering molecular sieve vessel for re-use to dewatera light hydrocarbon gas stream.
 8. The method of claim 7 wherein theaqueous amine comprises and amine selected from the group consisting ofdiglycolanolamine, methyldiethanolamine, methylethylanolamine, sulfinoland combinations thereof.
 9. The method of claim 7 wherein the lighthydrocarbon gas dewatering molecular sieve vessels contain a molecularsieve or activated alumina.
 10. The method of claim 7 wherein the spentdewatering vessels are thermally regenerated.
 11. A system fordewatering a light hydrocarbon gas feed stream to each of a plurality oflight hydrocarbon gas liquefaction trains, the system comprising: a) aplurality of molecular sieve dewatering vessels, each of the vesselshaving a gas inlet and a gas outlet so that an inlet gas can be changedto each dewatering vessel and a dewatered gas recovered from eachdewatering vessel; b) a light hydrocarbon gas supply line in fluidcommunication with each gas inlet; c) a dewatered light hydrocarbon gasrecovery line in fluid communication with each gas outlet line; and, d)a regeneration gas outlet line in fluid communication with eachdewatering vessel so that each dewatering vessel can be thermallyregenerated.
 12. The system of claim 11 wherein the number of dewateringvessels is less than or equal to an average run time for each of thedewatering vessels in dewatering service divided by the averageregeneration time for each of the dewatering vessels plus one or wholenumber multiples thereof.
 13. A system for removing acid gases anddewatering a light hydrocarbon gas feed stream to each of a plurality oflight hydrocarbon gas liquefaction trains, the system comprising: a) aplurality of aqueous amine acid gas removal vessels, each of the vesselshaving a gas inlet and a reduced acid gas outlet so that an inlet gascan be charged to each acid gas removal vessel and a gas having areduced acid gas content can be recovered from each acid gas removalvessel; b) a gas supply line in fluid communication with each gas inlet;c) a gas recovery line in fluid communication with each reduced acid gasoutlet; d) an aqueous amine regenerator having a spent amine inlet and aregenerated aqueous amine outlet; e) a regenerated aqueous amine inletin fluid communication with the regenerated aqueous amine outlet andeach acid gas removal vessel; f) a spent aqueous amine outlet in fluidcommunication with the spent aqueous amine inlet and each acid gasremoval vessel; and g) a plurality of molecular sieve dewateringvessels, each of the dewatering vessels having a reduced acid gas inletand a gas outlet so that a reduced acid gas inlet gas from an acid gasremoval vessel can be charged to each dewatering vessel and a dewateredgas recovered from each dewatering vessel; h) a gas supply line in fluidcommunication with at least one reduced acid gas outlet; i) a dewateredgas recovery line in fluid communication with each dewatered gas outletline and; j) a regeneration outlet line in fluid communication with eachdewatered vessel so that each dewatering vessel can be thermallyregenerated.
 14. A system for removing acid gases from a lighthydrocarbon gas feed stream to each of a plurality of light hydrocarbongas liquefaction trains, the system comprising: a) a plurality ofaqueous amine acid gas removal vessels, each of the vessels having a gasinlet and a reduced acid gas outlet so that an inlet gas can be changedto each acid gas removal vessel and a gas having a reduced acid contentcan be recovered from each acid gas removal vessel; b) a gas supply linein fluid communication with each gas inlet; c) a treated gas recoveryline in fluid communication with each gas outlet; d) a regeneratedaqueous amine inlet to each acid gas removal vessel; e) a spent aqueousamine outlet from each acid gas removal vessel; and, f) a spent aqueousamine regenerator in fluid communication with at least one selectedregenerated aqueous amine inlet and with at least one selected spentaqueous amine outlet. 15-17. (canceled)